Venezuela's Resurgence Will Not Displace Latin America's Oil Titans
In the landscape of oil production in Latin America, Argentina, Guyana, and Brazil are set to spearhead growth in 2026. Despite discussions regarding the potential resurgence of Venezuelan oil barrels, there are significant questions surrounding the long-term investment strategies within the region. Major oil companies continue to view Venezuela as a challenging environment for sustainable underwriting, yet traders and firms such as Trafigura and Hillcorp are increasingly attracted to immediate, structured opportunities within the country. This shift suggests a gradual reallocation of investment portfolios.
Although legal uncertainties and a lack of institutional legitimacy remain issues, recent reforms—like the easing of sanctions and revisions to Venezuela’s hydrocarbons legislation—are bolstering U.S. efforts to promote Venezuelan oil. According to analysis from Rystad Energy, key projects in Argentina, Guyana, and Brazil are projected to contribute over 700,000 barrels per day (bpd) to oil production this year, indicating that these nations are likely to maintain a competitive edge over Venezuela at least until 2030. In the near term, it is possible that an additional 300,000 bpd from Venezuela could enter the market. However, the prospect of diverting investments from established Latin American powerhouses to Venezuela—whose infrastructure faces numerous challenges—remains quite limited amid an unpredictable business climate.
Revamping Venezuela's oil industry will demand significant time and financial resources, and the region's leading players—Argentina, Guyana, and Brazil—are mostly indifferent to the anticipated short-term return of Venezuelan crude. The reality is that oversupply, whether stemming from Venezuelan or even Iranian sources, poses a real test to the financial stability of operators who would otherwise benefit from a revitalized oil sector in Venezuela.
Radhika Bansal, Vice President of Oil & Gas Research at Rystad Energy, notes that while overall investments in Latin America are expected to rise in 2026, the volume of conventional reserves being brought into production is estimated to be 45% lower than the previous year. This trend points toward a consolidation of investments in projects with almost guaranteed returns. Last year saw a significant drop in final investment decisions (FIDs) across the region, and 2026 appears unlikely to differ. Investments will primarily focus on greenfield projects in Guyana and Suriname, while Argentina is anticipated to lead the charge in brownfield investments as output from the Vaca Muerta formation accelerates.
The forecast for total oil production in the region is expected to surpass 8.8 million bpd this year, which will account for the majority of growth in non-OPEC+ supply. It is clear that Latin America is no longer functioning as a single oil-producing entity; the dynamics of the market are shifting as various players struggle to keep pace with the dominant trio driving the future of oil production. Brazil, in particular, is projected to be the main engine of growth in 2026, with production expected to exceed 4.2 million bpd. This increase is largely supported by the scale, resilience, and competitive cost structure of its pre-salt developments, driven by new floating production, storage, and offloading (FPSO) vessels coming online.
However, the real catalyst for increased investment within the region is its shale sector, which is anticipated to expand from $9.4 billion in 2025 to nearly $11 billion in 2026, solely from Argentina. Additionally, the offshore deepwater sector is projected to attract $42 billion in investments in 2026, marking a 7.7% increase from the previous year. This upward trajectory is supported by strong fundamentals in Vaca Muerta shale as well as resilient production from pre-salt fields and new explorations in Guyana and Suriname.
As for Venezuela, smaller companies are showing interest, driven by favorable licensing arrangements that help lower initial capital requirements. These arrangements also provide access to heavy crude supplies at attractive prices for refiners along the U.S. Gulf Coast. Traders are equipped to navigate the logistical, blending, and licensing hurdles associated with selling Venezuelan oil. Nonetheless, projects that demand lengthy development times and substantial upfront investments—such as those in offshore Brazil, Guyana, and Suriname—remain economically viable, even amidst fluctuations in oil prices, due to their competitive breakeven costs. The Vaca Muerta formation, while involving shorter cycle shale developments, is committed to enhancing its infrastructure, enabling it to respond resiliently to any potential recovery of Venezuelan oil production even in a declining price environment.
If demand for oil remains robust through 2035 and the ramifications of years of underinvestment become evident, Venezuelan oil could gain newfound relevance. Should industry stakeholders begin prioritizing more long-term, economically sensible decisions now, the case for Venezuelan oil production might strengthen in a higher price environment. However, it is crucial to note that more appealing alternatives will still be available, especially as Venezuela's extra-heavy and emissions-intensive oil continues to present ongoing challenges.
Radhika Bansal, Vice President of Oil & Gas Research, emphasizes that outside of the leading trio, nations situated nearer to Venezuela could establish different dynamics in an open exploration and production (E&P) market. For instance, Trinidad and Tobago may have the opportunity to utilize Venezuelan offshore gas to feed their liquefied natural gas (LNG) facilities. Conversely, Colombia might face heightened competition for capital, given the limited prospects left for oil exploration within its borders. Furthermore, the revival of Venezuela's oil sector may also lead to labor market competition, as the necessary skilled workforce for increased production might be drawn from neighboring Colombia.
